Drilling system and associated system and method for monitoring, controlling, and predicting vibration in an underground drilling operation

• US 10,472,944 B2
• Filed: 09/25/2013
• Issued: 11/12/2019
• Est. Priority Date: 09/25/2013
• Status: Active Grant

• Current Assignee: APS Technology Inc
• Original Assignee: APS Technology Inc
• Inventors: Wassell, Mark Ellsworth
• Primary Examiner(s): Perveen, Rehana
• Assistant Examiner(s): Luu, Cuong V
• Application Number:
  US14/036,577
• Publication Number:
  US 20150083492A1
• Time in Patent Office: 2,239 Days
• Field of Search: None
• CPC Class Codes: E21B 44/00 Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
• CPC Class Codes: E21B 47/007 Measuring stresses in a pipe string or casing for locating blocked portions of pipes E21B47/09

Abstract

A drilling system and associated systems and methods for monitoring, controlling, and predicting vibration of a drilling operation. The vibration information can include axial, lateral or torsional vibration of a drill string.

Claims

1. A method for monitoring and controlling a drilling system that includes a drill string and a drill bit supported at a downhole end of the drill string, the drilling system configured to form a borehole in an earthen formation, the method comprising the steps of:

predicting, via a drilling system model, vibration information for the drill string based on a set of drilling operating parameters and drilling system component information, the set of drilling operating parameters including a weight-on-bit (WOB) and a drill bit rotational speed and the drilling system component information including one or more characteristics of the drill string and the drill bit, the predicted vibration information including an amplitude for at least one of an axial vibration, lateral vibration, and a torsional vibration of the drill string, wherein the drilling system model predicts vibration information based on an energy balance of the drill string operating according to the set of drilling operating parameters during an expected drilling operation, wherein the energy balance is a balance of an energy supplied to the drilling system with an energy dissipated from the drilling system, wherein the energy supplied is the product of at least the distributed force, a function of the phase angle, and a function of the displacement along the drill string, and the energy dissipated is the product of at least the spring rate, damping coefficient, and displacement of the drill string components, as a function of forces applied to the drill string;

operating the drilling system to drill the borehole in the earthen formation according to the set of drilling operating parameters;

measuring in the borehole during the drilling operation at least one of the axial vibration, lateral vibration, and a torsional vibration of the drill string; and

comparing the predicted vibration information for the drill string and the drill bit to the measured vibration information for the drill string and the drill bit, and if the step of comparing results in a difference between the expected and measured vibration information for each of the drill string and the drill bit, updating the drilling system model to reduce the difference between the expected and measured vibration information for the drill string and the drill bit.

2. The method of claim 1, wherein predicting vibration information is based upon information indicating a relative mode shape efficiency for each one of the axial vibration, the lateral vibration, and the torsional vibration.

3. The method of claim 1, wherein the step of predicting vibration information is based on a frequency domain type of finite element model by applying the energy balance to the drill string as a function of one or more forces applied to the drill string.

4. The method of claim 1, further comprising the step of accessing the set of drilling operating parameters for a drilling operation, the set of drilling operating parameters selected so as to attain an expected maximum rate-of-penetration through the earthen formation.

5. The method of claim 4, further comprising the step of accessing borehole information, wherein the borehole information includes a borehole diameter.

6. The method of claim 4, wherein the step of accessing the set of drilling operating parameters further comprises receiving the set of drilling operating parameters.

7. The method of claim 6, wherein the step of accessing borehole information further comprises receiving borehole information.

8. The method of claim 1, based on an adjustment to one or more of the set of drilling operating parameters, further predicting via the updated drilling system model the vibration information for the drill string and the drill bit based on the adjusted set of drilling operating parameters, the borehole information, and the drilling system component information.

9. The method of claim 1, wherein the drilling operation includes one or more drill runs of the drill string to form the borehole in the earthen formation.

10. The method of claim 1, further comprising the step of determining critical speeds for the drill string based on the set of operating parameters and the vibration information of the drill string and drill bit.

11. A drilling system configured to form a borehole in an earthen formation during a drilling operation, the drilling system comprising:

a drill string supporting a drill bit, the drill bit configured to define the borehole;

a plurality of sensors configured to obtain drilling operation information and measured vibration information, wherein one or more of the plurality of sensors are configured to measure in the borehole during the drilling operation, at least one of an axial vibration, lateral vibration, and a torsional vibration of the drill string so as to obtain the measured vibration information;

at least one computing device including a memory portion having stored thereon drilling system component information, the drilling system component information including one or more characteristics of the drill string, the memory portion further including expected operating information for the drilling operation, the expected operating information including at least a weight-on-bit (WOB), a rotational speed of the drill bit, a borehole diameter, and a vibration damping coefficient; and

a computer processor in communication with the memory portion, the computer processor configured to predict vibration information for the drill string, the predicted vibration information including at least a predicted amplitude for at least one of the axial vibration, the lateral vibration, and the torsional vibration of the drill string, the predicted vibration information being based on the drilling system component information and an energy balance of the drill string operating according to the expected operation information for the drilling operation, wherein the energy balance includes a balance of an energy supplied to the drilling system with an energy dissipated from the drilling system, wherein the energy supplied is the product of at least the distributed force, a function of the phase angle, and a function of the displacement along the drill string, and the energy dissipated is the product of at least the spring rate, damping coefficient, and displacement of the drill string components, as a function of forces applied to the drill string,

the computing processor being further configured to compare the predicted vibration information for the drill string and the drill bit to the measured vibration information for the drill string and the drill bit, wherein the computing device is configured to update the drilling system model if a difference between the expected and measured vibration information is detected.

12. The drilling system of claim 11, wherein the predicted vibration information is based upon information indicating a relative mode shape efficiency for each one of the axial vibration, the lateral vibration, and the torsional vibration.

13. The drilling system of claim 11, wherein the predicted vibration information is based on a frequency domain type of finite element model that applies the energy balance to the drill string as a function of one or more forces applied to the drill string.

14. The drilling system of claim 11, wherein the predicted vibration is the mode shape for at least one of axial, lateral and torsional vibration along the drill string.

15. The drilling system of claim 11, wherein the one or more characteristics of the drill string include a drill string geometry, material properties of the drill string, location and number of stabilizers on the drill string, inclination of the drill string, and drill bit geometry.

16. The drilling system of claim 11, further comprising a communications system configured to transmit data obtained downhole during the drilling operation to the at least one computing device.

17. The drilling system of claim 16, wherein the communications system is pulse telemetry system.

18. The drilling system of claim 16, wherein the communications system is a wired system.

19. The drilling system of claim 11, wherein the drill string supports a bottomhole assembly at a downhole end of the drill string, and the drill bit is coupled to the bottomhole assembly, wherein the plurality of sensors includes a first set of sensors carried by the bottomhole assembly, a second set of sensors disposed along the drill string, and a third set of sensors disposed on a surface structure of the drilling system.